Southeastern Colorado Water inks agreement with Fountain and Fort Carson for hydro project

The new north outlet works at Pueblo Dam — Photo/MWH Global

From The Colorado Springs Gazette (Conrad Swanson):

The Southeastern Colorado Water Conservancy District and the U.S. Bureau of Reclamation, which owns and operates the Pueblo Dam, signed an agreement last week allowing for the soon-to-be-built plant to connect to the dam, Chris Woodka, the district’s issues management program coordinator, said in a release.

The agreement was signed after the Colorado Springs City Council unanimously approved the creation of a military sales tariff on Tuesday. The tariff will cover costs for Colorado Springs Utilities to act as an intermediary, buying power from the district and selling it to Fort Carson.

With all the necessary agreements in place, the district hired Mountain States Hydro, LLC, to build the $19 million plant, Woodka said. Construction will begin in September and the plant should be operational by the spring.

Half of the electricity from the plant, estimated to be up to 7.5 megawatts, will be sold to Fort Carson and the other half will be sold to Fountain Utilities.

The plant is expected to generate about $1.4 million in revenue each year, Woodka said.

From The Pueblo Chieftain (Jon Pompia):

“This is a monumental moment in the history of the district,” said Jim Broderick, the district’s executive director. “We have been working to put all of the pieces in place since 2011. Now that this project is coming to fruition, it represents not only a sustainable income stream for our stakeholders, but develops a clean source of power for the future.”

Added Chris Woodka, the district’s issues management program coordinator, “The Lease of Power Privilege clears the way for the hydropower plant to connect to Pueblo Dam, a federally owned structure. Mike Ryan, director of the Great Plains Region for Reclamation, signed the lease Friday.”

In order to satisfy all federal requirements related to the project, members of the district have been working for the past 18 months to put a series of other agreements in place.

“The district has contracted with Mountain States Hydro, LLC, to build the plant,” Woodka said, “with construction to begin in September. It is scheduled to be completed during the fall and winter months when releases from Pueblo Dam generally decrease.”

It’s anticipated that the plant will be online by spring 2018.

The plant will cost about $19 million to build. Last year, the district secured a $17.2 million loan from the Colorado Water Conservation Board, with the district’s business enterprise providing matching funds.

Over time, those funds will be paid off by revenues from the sale of power.

For a decade, power from the plant will be purchased by the city of Fountain and by Colorado Springs Utilities for use at Fort Carson.

“After that, Fountain intends to purchase all of the power for at least 20 more years,” Woodka said.

The plant will generate up to 7.5 megawatts of power by using three turbines capable of producing power from 35 to 800 cubic feet per second of flow in the Arkansas River. Water will pass through a connection that was built into the service line for the Southern Delivery System, then into the Arkansas River.

Projections by district staff show that an average of 28 million kilowatt hours will be produced annually, with about $1.4 million in average revenue per year.

This money will be used to pay off the CWCB loan and to satisfy contractual agreements with the Bureau of Reclamation, as well as a carriage agreement with Black Hills Energy. All remaining funds will go to enterprise activities, including the Arkansas Valley Conduit.

@CSUutilities hydroelectric plant at Pueblo Reservoir will supply Fort Carson

The new north outlet works at Pueblo Dam — Photo/MWH Global

From The Colorado Springs Gazette (Conrad Swanson):

A hydroelectric plant is planned for construction downstream from the Pueblo Dam to generate renewable energy for Fort Carson. Developers are just waiting for the signal to start building.

The plant would significantly increase the amount of renewable energy Fort Carson consumes, fitting with the post’s “Net Zero” goals of becoming more environmentally friendly.

The Colorado Springs Utilities board will consider adding a military sales tariff during its meeting Wednesday. The tariff would cover costs for Utilities to act as an intermediary, selling the power to Fort Carson after buying it from the Southeastern Colorado Water Conservancy District, which would build and operate the plant, said Utilities spokeswoman Amy Trinidad.

Adding the tariff is the “last step” before the district can begin construction, said spokesman Chris Woodka.

“We’ve been ready to pull the trigger on this since January,” he said.

Currently, 8 percent of Fort Carson’s electricity is generated on-site through renewable sources such as solar panels, post spokeswoman Dani Johnson said. She could not say whether the post buys any renewable energy from off-site sources.

But Trinidad said Fort Carson does buy some renewable energy from Utilities. She could not say how much, citing customer privacy. The proposed hydroelectric deal would make up 7 percent of the post’s annual electricity purchase from Utilities, she said.

If the tariff is added, the proposal then will go before the City Council, consisting of the same members as the Utilities board, next month. If the council approves the move, construction on the plant can begin, Woodka said.

The plant would cost about $19 million, most of which comes from a loan the district took out, he said. In the years to come, energy sales are expected to cover the costs and eventually generate funds.

The plant’s construction will not have a financial impact on Utilities ratepayers, Trinidad said.

The plant is expected to generate up to 7.5 megawatts of electricity, Woodka said. Fort Carson will buy half of that, and Fountain Utilities will buy the other half.

The plant could be operational by May 2018, a peak time for generating hydroelectricity because of the high volume of water flowing from the Pueblo Dam, Woodka said.

Utilities then would buy the electricity, which will be transmitted onto its grid, and then sell it to Fort Carson without marking up the price, Trinidad said.

In the past, Fort Carson bought renewable wind energy through Utilities under short-term contracts, which have since expired, said Steve Carr, Utilities’ key account manager for Fort Carson. The pending hydroelectricity contract would last until the end of 2027.

HydroVision conference recap

Here’s a guest column from Bob Gallo writing in the Denver Business Journal. Here’s an excerpt:

While the groundwork to unlock hydropower’s full potential has been laid, there is much more left to be done. The manufacturers, developers, engineers, consultants, utility managers, and others who came to Denver last week certainly agreed.

Congress also agrees that hydropower should be an important part of the country’s energy future. Last year, the Energy Policy Modernization Act (EPMA) nearly made it across the finish line before running out of time as Congress adjourned for the year. EPMA enjoyed broad bipartisan support, and contained many hydropower provisions long sought by the industry, including designating the Federal Energy Regulatory Commission (FERC) as the lead agency for licensing hydropower projects. These changes would reduce unnecessary delays and uncertainty.

Though that effort ultimately fell short, hydropower remains the one energy source that can narrow the massive chasm between the two political parties on energy. Just six months into the current legislative session, no less than 33 bills focused on hydropower have been introduced. Nearly every week, committees in the House and Senate are holding hearings or markups on hydro legislation. Republicans and Democrats alike are seeing the value in hydropower and exploring more ways to get this valuable energy source online.

This is particularly true for the Colorado delegation. Earlier this year, Rep. Doug Lamborn, R-Colorado, introduced legislation that would encourage pumped storage hydropower at U.S. Bureau of Reclamation facilities. Pumped storage is the only proven large-scale energy storage technology and should be utilized to a much greater extent than it is currently.

Sen. Cory Gardner, R-Colorado, recently sponsored a bill that would reauthorize a Department of Energy Waterpower program that provides funding to retrofit dams and river conduits with electricity. There are over 80,000 dams in the country, and only 3 percent produce power. These non-powered dams hold great promise for additional generation.

Rep. DeGette has continued her leadership on hydropower, co-sponsoring new legislation earlier this month that would reduce the timeframe for approval of conduit hydro projects on Bureau facilities. The Colorado Small Hydro Association estimates that these types of canals and conduits could power an additional 65,000 Colorado homes…

The hydropower licensing process is one major roadblock to increasing our current installed hydropower capacity from 100 gigawatts to 150 gigawatts by 2050 – a goal set forth in the Department of Energy’s 2016 Hydropower Vision report. By utilizing some of those tens of thousands of untapped dams in the U.S., boosting pumped storage, and efficiency upgrades at existing facilities, hydropower can be a big part of our energy future. According to an earlier report, Colorado alone could produce 3.8 gigawatts of additional hydropower.

There’s an important side benefit to hydropower: infrastructure investment and job creation.

#Colorado Dept. of Agriculture has funding for farm hydropower projects

Hydropower sprinkler system via Homelink Magazine

From the Colorado Department of Agriculture via The Fence Post:

The Colorado Department of Agriculture and the U.S. Department of Agriculture’s Natural Resources Conservation Service are seeking applicants for on-farm agricultural hydropower projects. The total amount of available assistance for this round is $1,200,000. The funding is available to Colorado agricultural irrigators with appropriate hydropower resources.

The funding is part of the NRCS Regional Conservation Partnership Program. Within RCPP, the Colorado irrigation hydropower program provides funding to agricultural producers to help them add hydropower to new or existing irrigation systems.

“The program addresses water quantity, water quality and energy resource concerns,” said Sam Anderson, CDA’s energy specialist, “by helping farmers upgrade outdated and labor-intensive flood-irrigation systems to more efficient pressurized-irrigation systems using hydropower, or retrofit existing sprinkler systems with a hydropower component.

“Half a dozen projects have already been completed across Colorado, and this year we hope to fund more than a dozen new installations,” he said.

“This program helps farmers by putting their irrigation water to work, creating electricity that lowers their power bills,” Commissioner of Agriculture Don Brown said. “We are very proud of this program and how it gives producers a way to cut their costs and use their resources efficiently.”

The overall hydro program is funded and assisted by 14 agencies and groups, collectively contributing $3 million to the effort for project funding and technical assistance for Colorado agricultural producers.

CDA is currently accepting applications for the next round of RCPP irrigation hydro projects. Applicants must be eligible to receive funding from the NRCS EQIP program. For more information and to submit an application, visit the Colorado Department of Agriculture’s ACRE3 hydropower website: http://www.colorado.gov/agconservation/hydro-navigation-guide or contact Sam Anderson at (303) 869-9044 or http://CDA_hydro@state.co.us. The application deadline is June 23, 2017.

Carbondale micro hydro project cruising to approval — @AspenJournalism

Micro-hydroelectric plant

From Aspen Journalism (Brent Gardner-Smith) via The Glenwood Springs Post-Independent:

On March 9 the town of Carbondale notified the Federal Energy Regulatory Commission it plans to install a micro hydropower turbine in a pipe leading to its municipal water treatment plant on Nettle Creek.

On March 13 FERC found that Carbondale’s project qualified for a quick review under the Hydropower Regulatory Efficiency Act of 2013, which streamlined the permitting process for hydro projects of less than 5 megawatts.

And by April 27, if no one claims the project doesn’t qualify, the town can expect to get a letter from FERC saying the town does not need a license and can go ahead, at least as far is FERC is concerned.

At 28 kilowatts, Carbondale’s project is much smaller than the 5-megawatt limit in the efficiency act, it’s a new license using a nonfederal pipeline, and it complies with the Federal Power Act.

So far, FERC’s fine with it, and it’s received no objections from the public.

The project involves installing a “turbine/generating unit” in an existing 10-inch municipal pipeline, or “raw water intake line.”

The pipe is 1,800 feet long and transports about 1 cubic foot per second of water downhill from Nettle Creek to the city’s treatment plant. The plant is eight miles up the Crystal River valley on the lower slope of Mount Sopris.

The turbine would be built inside a vault installed in the pipeline, near the treatment plant. A short bypass system would allow water to be moved around the turbine for repairs and maintenance.

“It’s taking advantage of the water that is already going down that pipeline,” said Mark O’Meara, Carbondale’s utilities director. “We’re not going to increase it. We’re not going to be doing any additional diversion.”

O’Meara also said that since it’s a nonconsumptive use of water already running down a pipeline, the town did not have to change its existing municipal water rights to specifically add hydro as a use.

The turbine’s “installed capacity” of 28 kilowatts and its “estimated annual generating capacity” of 190,000 kilowatt-hours is about enough electricity to offset the amount of power used to run the water plant, O’Meara said.

According to Craig Cano, a media relations officer at FERC, the 28 kilowatt figure refers to how much power the turbine could produce at any moment.

“That’s real small,” Cano said, pointing out it’s 0.028 of a megawatt, while a typical baseload-generating power plant’s capacity is in the hundreds of megawatts.

The 190,000 kilowatt-hour figure refers to the total amount of energy produced over a year.

The resulting electricity would either be sent through the existing Holy Cross Energy system that today powers the plant, or perhaps be used directly in the plant, O’Meara said. The town would get credit from Holy Cross for hydropower sent out over the grid.

The project has been in the works since the 1990s, but it still has a long way to go.

On the list is an in-depth feasibility study considering design, engineering and cost. A 2012 estimate from engineering firm SGM put the cost at $180,000. O’Meara did not have an updated cost.

And since the water plant and pipeline are on U.S. Forest Service land, the agency also has jurisdiction over the project.

But O’Meara said after going to a recent workshop put on by the Colorado Energy Office, it seemed like the right time for the town to enter the streamlined FERC process and see how it goes.

It took only four days after receiving Carbondale’s “notice of intent” for FERC to issue its “notice of preliminary determination” that the project qualified for speedy review.

That notice, along with town’s initial notice, are on town’s website, on its utilities page.

Also on March 13, FERC opened two windows for parties to contest the qualifications of the project.

The first was a 30-day window to file a motion to intervene. By April 12, no one had.

The second was a 45-day window for less formal but still “contesting” comments to be made.

That window closes April 27, and as of April 13, FERC had received no comments.

“If no party contests staff’s initial determination that the project meets the criteria for a qualifying conduit hydropower facility within the 45-day public notice period,” FERC’s Cano said, “the facility is deemed to meet the criteria and FERC staff shortly thereafter will issue a letter notifying the filer that is project has met the criteria.”

If someone does file a comment contesting the project’s qualifications, FERC is supposed to then “promptly issue a written determination as to whether the facility meets the criteria,” Cano said.

Carbondale’s O’Meara said that as far as he knows, no one over the years has raised concerns about the project directly to the town.

Aspen Journalism is collaborating with the Post Independent, The Aspen Times, the Vail Daily and the Summit Daily News on coverage of water in the upper Colorado River basin. More at http://www.aspenjournalism.org.

@Northern_Water 2017 quota set at 80%

Map of the Colorado-Big Thompson Project via Northern Water

Here’s the release from Northern Water:

Northern Water’s Board increased the Colorado-Big Thompson Project quota allocation to 80 percent at its April 13 Board meeting. With many farmers concerned about the lack of recent moisture and the hope that cities may be willing to provide some rental water to help the region’s agricultural economy, the Board chose to make available an additional 30 percent as supplemental quota for 2017.

The approval increased available C-BT water supplies by 93,000 acre-feet, from the initial 50 percent quota made available last November.

The Board considered snowpack totals, streamflow runoff projections and input from farmers and municipal and industrial water providers in setting the quota. C-BT supplements other sources of water for 33 cities and towns, 120 agricultural irrigation companies, various industries and other water users within Northern Water’s 1.6 million-acre service area.

Directors considered the general dearth of moisture in March as they discussed the quota options. March precipitation was 27 percent below normal and contributed to the Board’s decision to raise the quota.

“It’s dry, it really is,” said Board President Mike Applegate. “The C-BT Project was created to provide a supplemental supply and we have the reserves to do that.”

He echoed the Board’s consensus in making its 61st annual C-BT quota. “Let’s make the water available now so our allottees can make their plans.”

Directors base their decision on the region’s need for supplemental water, while balancing project operations and maintaining water in storage for future dry years.

To learn more about Northern Water and the C-BT quota, visit http://www.northernwater.org.

Lake Granby spill June 2011 via USBR. Granby Dam was retrofitted with a hydroelectric component and began producing electricity [in 2011] as water is released in the Colorado River.

Senate confirms Zinke as Interior Secretary

Arizona Water News

The new Zinke team, including appointments to Bureau of Reclamation, will need to learn quickly about the complexities of Colorado River water law and the drought-induced woes facing Lake Mead

zinke-confirmation-photo

By a comfortable 68-31 margin, the U.S. Senate today confirmed President Trump’s nominee for Secretary of the Interior, Ryan Zinke.

The former Montana member of Congress will head a department that manages around 500 million acres of land and waterways in the United States.

Zinke’s department also includes the federal Bureau of Reclamation, the agency responsible for the system of dams and reservoirs on the Colorado River, the waterway that is integral to the livelihood of 40 million U.S. citizens living in the Southwest.

In a statement declaring his approval of the appointment, Arizona Sen. Jeff Flake said he looked forward to working with Zinke’s department, notably on behalf of Arizona’s Colorado River allotment.

“I was pleased to vote to…

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